WO2024059602A1 - Procédés de réaction d'hydrocarbures à l'aide de dispositifs d'extraction - Google Patents

Procédés de réaction d'hydrocarbures à l'aide de dispositifs d'extraction Download PDF

Info

Publication number
WO2024059602A1
WO2024059602A1 PCT/US2023/074024 US2023074024W WO2024059602A1 WO 2024059602 A1 WO2024059602 A1 WO 2024059602A1 US 2023074024 W US2023074024 W US 2023074024W WO 2024059602 A1 WO2024059602 A1 WO 2024059602A1
Authority
WO
WIPO (PCT)
Prior art keywords
particulate solid
reactor
strip
strip zone
gas
Prior art date
Application number
PCT/US2023/074024
Other languages
English (en)
Inventor
Matthew T. Pretz
Davy Nieskens
Original Assignee
Dow Global Technologies Llc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Dow Global Technologies Llc filed Critical Dow Global Technologies Llc
Publication of WO2024059602A1 publication Critical patent/WO2024059602A1/fr

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C5/00—Preparation of hydrocarbons from hydrocarbons containing the same number of carbon atoms
    • C07C5/42—Preparation of hydrocarbons from hydrocarbons containing the same number of carbon atoms by dehydrogenation with a hydrogen acceptor
    • C07C5/48—Preparation of hydrocarbons from hydrocarbons containing the same number of carbon atoms by dehydrogenation with a hydrogen acceptor with oxygen as an acceptor
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J23/00—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00
    • B01J23/08—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of gallium, indium or thallium
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J23/00—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00
    • B01J23/38—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of noble metals
    • B01J23/40—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of noble metals of the platinum group metals
    • B01J23/42—Platinum
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J29/00—Catalysts comprising molecular sieves
    • B01J29/04—Catalysts comprising molecular sieves having base-exchange properties, e.g. crystalline zeolites
    • B01J29/06—Crystalline aluminosilicate zeolites; Isomorphous compounds thereof
    • B01J29/40—Crystalline aluminosilicate zeolites; Isomorphous compounds thereof of the pentasil type, e.g. types ZSM-5, ZSM-8 or ZSM-11, as exemplified by patent documents US3702886, GB1334243 and US3709979, respectively
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J29/00—Catalysts comprising molecular sieves
    • B01J29/90—Regeneration or reactivation
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J38/00—Regeneration or reactivation of catalysts, in general
    • B01J38/04—Gas or vapour treating; Treating by using liquids vaporisable upon contacting spent catalyst
    • B01J38/12—Treating with free oxygen-containing gas
    • B01J38/22—Moving bed, e.g. vertically or horizontally moving bulk
    • B01J38/26—Moving bed, e.g. vertically or horizontally moving bulk having mainly counter-current flow of oxygen-containing gas and material
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C5/00—Preparation of hydrocarbons from hydrocarbons containing the same number of carbon atoms
    • C07C5/42—Preparation of hydrocarbons from hydrocarbons containing the same number of carbon atoms by dehydrogenation with a hydrogen acceptor

Definitions

  • Embodiments described herein generally relate to chemical processing and, more specifically, to processes and systems utilized for the formation of olefinic compounds.
  • Olefinic compounds may be utilized as base materials to produce many types of goods and materials.
  • ethylene may be utilized to manufacture polyethylene, ethylene chloride, or ethylene oxides.
  • Such products may be utilized in product packaging, construction, textiles, etc.
  • olefinic compounds such as ethylene, propylene, butene, and styrene.
  • Olefinic compounds may be formed from various hydrocarbon feeds.
  • olefinic materials may be formed by the dehydrogenation of alkanes (catalytic or thermal).
  • particulate solids are utilized, which may generally cycle between a reactor and a regeneration unit.
  • coke may form on the particulate solid.
  • the coke is combusted in the regeneration unit, forming CO2 that is eventually expelled to the environment. This is not ideal, since CO2 is a known greenhouse contributing gas.
  • coke in such processes may be reacted in a strip zone with oxygen to form CO2, which is combined with the olefinic products.
  • the CO2 may be subsequently separated from the olefinic products and not released into the environment.
  • olefinic compounds may be formed by a process comprising contacting a feed stream comprising one or more hydrocarbons with a particulate solid in a reactor.
  • the one or more hydrocarbons may be reacted to form one or more olefinic compounds and coke may form on the particulate solid.
  • the process may further comprise passing the particulate solid from the reactor to a strip zone.
  • the particulate solid may be contacted with a strip gas and oxygen.
  • the strip gas may comprise nitrogen, steam, or combinations thereof.
  • a majority of the coke may be reacted with oxygen to form carbon dioxide.
  • the majority of the carbon dioxide produced in the strip zone may be passed out of the strip zone and combined with the one or more olefinic compounds.
  • the process may further comprise passing the particulate solid from the strip zone to a regeneration unit, wherein the particulate solid may be heated by combustion of a fuel in the regeneration unit.
  • the process may further comprise passing at least a portion of the particulate solid from the regeneration unit to the reactor.
  • FIG. 1 schematically depicts a reactor system, according to one or more embodiments of the present disclosure.
  • FIG. 2 schematically depicts another reactor system, according to additional embodiments of the present disclosure.
  • the numerous valves, temperature sensors, electronic controllers, and the like which may be used and are well known to a person of ordinary skill in the art, are not included.
  • accompanying components that are often included in such reactor systems such as air supplies, heat exchangers, surge tanks, and the like are also not included. However, it should be understood that these components are within the scope of the present disclosure.
  • Embodiments presently disclosed are described in detail herein in the context of the reactor systems of FIG. 1 and FIG. 2 operating as a fluidized dehydrogenation reactor system to produce light olefins, such as propylene.
  • the principles disclosed and taught herein may be applicable to other systems which utilize different system components oriented in different ways, or different reaction schemes utilizing various catalyst compositions.
  • the concepts described may be equally applied to other systems with alternate reactor units and regeneration units, such as those that operate under non-fluidized conditions or include downers rather than risers.
  • not all portions of the reactor systems of FIG. 1 and FIG. 2 should be construed as essential to the claimed subject matter.
  • the reactor system 102 generally comprises multiple system components, such as a reactor portion 200 and a regeneration unit 300.
  • system components refer to portions of the reactor system 102, such as reactors, separators, transfer lines, combinations thereof, and the like.
  • the reactor portion 200 generally refers to the portion of a reactor system 102 in which the major process reaction takes place (e.g., dehydrogenation) to form the product stream.
  • a feed stream enters the reactor portion 200, is converted to a product stream (containing product and unreacted feed), and exits the reactor portion 200.
  • the reactor portion 200 comprises a reactor 202 which may include an upstream reactor section 250 and a downstream reactor section 230.
  • the reactor portion 200 may additionally include a particulate solid separation section 210, which serves to separate the particulate solid from the chemical products formed in the reactor 202.
  • the particulate solid may pass through a strip zone 224 before being passed to the regeneration unit 300.
  • an oxygen-containing gas may enter into the strip zone 224 through a first gas inlet 520.
  • a strip gas may enter into the strip zone 224 through a second gas inlet 510.
  • the particulate solid may be exposed to the oxygen-containing gas in the strip zone 224 before being passed to the regeneration unit 300.
  • the regeneration unit 300 generally refers to the portion of the reactor system 102 where the particulate solid is in some way processed, such as by combustion, to, e.g., improve catalytic activity and/or heat the particulate solid.
  • the regeneration unit 300 may comprise a combustor 350 and a riser 330, and may additionally comprise a particulate solid separation section 310.
  • the particulate solid separation section 210 may be in fluid communication with the combustor 350 (e.g., via standpipe 426) and the particulate solid separation section 310 may be in fluid communication with the upstream reactor section 250 (e.g., via standpipe 424 and transport riser 430).
  • the particulate solid is cycled between the reactor portion 200 and the regeneration unit 300.
  • particulate solids may refer to solid materials that are catalytically active for a desired reaction, or may equally refer to other particulate solids referenced with respect to the systems of FIG. 1 and FIG. 2 which do not necessarily have catalytic activity but affect the reaction, such as oxygen-carrier materials.
  • catalytic activity and “catalyst activity” refer to the degree to which the particulate solid is able to catalyze the reactions conducted in the reactor system 102.
  • the particulate solid that exits the reactor portion 200 may be deactivated particulate solid.
  • deactivated may refer to a particulate solid which has reduced catalytic activity or is cooler as compared to particulate solid entering the reactor portion 200. However, deactivated particulate solid may maintain some catalytic activity. Reduced catalytic activity may result from contamination with a substance such as coke. Reactivation (sometimes called “regeneration” herein) may remove the contaminant such as coke, raise the temperature of the particulate solid, or both. In embodiments, a majority of the coke formed on the particulate solid may be reacted with oxygen in the strip zone 224 before the particulate solid is passed to the regeneration unit 300.
  • deactivated particulate solid may be reactivated by particulate solid reactivation in the regeneration unit 300.
  • the deactivated particulate solid may be reactivated by, but not limited to, removing coke by combustion, recovering catalyst acidity, oxidizing the particulate solid, other reactivation process, or combinations thereof.
  • the particulate solid may be heated during reactivation by combustion of a fuel, such as hydrogen, methane, ethane, propane, natural gas, or combinations thereof.
  • the reactivated particulate solid from the regeneration unit 300 may then be passed back to the reactor portion 200.
  • the feed stream may enter feed inlet 434 into the reactor 202, and the product stream may exit the reactor system 102 via pipe 420.
  • the reactor system 102 may be operated by feeding a chemical feed (e.g., in a feed stream) and a fluidized particulate solid into the upstream reactor section 250.
  • the chemical feed contacts the particulate solid in the upstream reactor section 250, and each flow upwardly into and through the downstream reactor section 230 to produce a chemical product.
  • the reactor portion 200 may comprise an upstream reactor section 250, a transition section 258, and a downstream reactor section 230, such as a riser.
  • the transition section 258 may connect the upstream reactor section 250 with the downstream reactor section 230.
  • the upstream reactor section 250 may be positioned below the downstream reactor section 230.
  • Such a configuration may be referred to as an upflow configuration in the reactor 202.
  • the upstream reactor section 250 may include a vessel, drum, barrel, vat, or other container suitable for a given chemical reaction.
  • the upstream reactor section 250 may be connected to the downstream reactor section 230 via the transition section 258.
  • the upstream reactor section 250 may generally comprise a greater cross- sectional area than the downstream reactor section 230.
  • the transition section 258 may be tapered from the size of the cross-section of the upstream reactor section 250 to the size of the crosssection of the downstream reactor section 230 such that the transition section 258 projects inwardly from the upstream reactor section 250 to the downstream reactor section 230.
  • the transition section 258 may be a frustum.
  • the upstream reactor section 250 may be connected to a transport riser 430, which, in operation may provide reactivated particulate solid in a feed stream to the reactor portion 200.
  • the reactivated catalyst and/or reactant chemicals may be mixed with a distributor 260 housed in the upstream reactor section 250.
  • the particulate solid entering the upstream reactor section 250 via transport riser 430 may be passed through standpipe 424 to a transport riser 430, thus arriving from the regeneration unit 300.
  • particulate solid may come directly from the particulate solid separation section 210 via standpipe 422 and into a transport riser 430, where it enters the upstream reactor section 250, where in such embodiments some of the particulate solid is not passed through the regeneration unit 300.
  • the particulate solid can also be fed via standpipe 422 directly to the upstream reactor section 250 (not depicted in FIG. 1). This particulate solid may be somewhat deactivated, but may still, in some embodiments, be suitable for reaction in the upstream reactor section 250, particularly when used in combination with reactivated particulate solid.
  • the upstream reactor section 250 may operate as a fluidized bed, such as in a fast fluidized, turbulent, or bubbling bed upflow reactor, while the downstream reactor section 230 may operate in more of a plug flow manner, such as in a riser reactor.
  • the reactor 202 of FIG. 1 may comprise an upstream reactor section 250 operating as a fast fluidized, turbulent, or bubbling bed reactor and a downstream reactor section 230 operating as a dilute phase riser reactor, with the result that the average particulate solid and gas flow moves concurrently upward.
  • a “fast fluidized” reactor may refer to a reactor utilizing a fluidization regime wherein the superficial velocity of the gas phase is greater than the choking velocity and may be semi-dense in operation.
  • a “turbulent” reactor may refer to a fluidization regime where the superficial velocity of less than the choking velocity and is more dense than the fast fluidized regime.
  • a “bubbling bed” reactor may refer to a fluidization regime wherein well defined bubbles in a highly dense bed are present in two distinct phases.
  • choking velocity refers to the minimum velocity required to maintain solids in the dilute -phase mode in a vertical conveying line.
  • a “dilute phase riser” may refer to a riser reactor operating at transport velocity, where the gas and particulate solid have about the same velocity in a dilute phase.
  • the chemical product and the particulate solid may be passed out of the downstream reactor section 230 to a separation device 220 in the particulate solid separation section 210, where the particulate solid is separated from the chemical product, which is transported out of the particulate solid separation section 210.
  • the particulate solid following separation from vapors in the separation device 220, the particulate solid may generally move through the strip zone 224 to the particulate solid outlet port 222 where the particulate solid is transferred out of the reactor portion 200 via standpipe 426 and into the regeneration unit 300.
  • the strip zone 224 may comprise a first gas inlet 520 and a second gas inlet 510.
  • the strip zone 224 is an area where stripping may occur. Stripping is a process by which entrained and adsorbed products and reactants from reactor may be removed from the particulate solid through the use of a strip gas. For example, during of the dehydrogenation of ethane stripping may remove ethane, ethylene, and other hydrocarbon by products.
  • An oxygen-containing gas may enter the strip zone 224 through the first gas inlet 520.
  • a strip gas may enter the strip zone 224 through the second gas inlet 510.
  • the strip gas may comprise nitrogen, steam or combinations thereof.
  • the particulate solid may move in a generally downwards direction through the strip zone 224.
  • generally downward direction means that the average velocity of the particulate solid is in the downward direction, where the downward direction is with the pull of gravity.
  • the velocity of individual particles of the particulate solid may have a distribution and may not be equal to the average, but taken as a whole the velocity of the particulate solid will average out to be generally downward.
  • gases within the strip zone 224 may move in a generally upwards direction through the strip zone 224.
  • general upward direction means that the average velocity of gases within the strip zone 224 is in the upward direction, where the upward direction is against the pull of gravity.
  • the velocity of the gas molecules within the strip zone 224 may have a distribution and may not be equal to the average, but taken as a whole the velocity of the gases will average out to be generally upward.
  • the particulate solid and the gases may move in a countercurrent flow pattern through the strip zone 224.
  • the first gas inlet 520 may be above the second gas inlet 510 as shown in FIG. 1. In some embodiments, the first gas inlet 520 may be below the second gas inlet 510. In some embodiments, the first gas inlet 520 and the second gas inlet 510 may be at the same height within the strip zone 224.
  • an oxygen-containing gas may enter the strip zone 224 through the first gas inlet 520.
  • the oxygen-containing gas may be air, enriched air, air mixed with steam, or flue gas. Enriched air is air with added oxygen.
  • the oxygen-containing gas may include at least 28 mol.% oxygen.
  • the oxygen-containing gas may include from about 2 mol.% to about 28 mol.% oxygen, from about 2 mol.% to about 25 mol.% ,from about 2 mol.% to about 20 mol.%, from about 2 mol.% to about 15 mol.%, from about 2 mol.% to about 10 mol.%, from about 2 mol.% to about 5 mol.%, from about 5 mol.% to about 28 mol.%, from about 5 mol.% to about 25 mol.%, from about 5 mol.% to about 20 mol.%, from about 5 mol.% to about 15 mol.%, from about 5 mol.% to about 10 mol.%, from about 10 mol.% to about 28 mol.%, from about 10 mol.% to about 25 mol.%, from about 10 mol.% to about 20 mol.%, from about 10 mol.% to about 15 mol.%, from about 15 mol.% to about 28 mol.%, from about 10 mol
  • At least a portion of the coke that forms on the particulate solid may react with oxygen in the strip zone 224 to produce carbon dioxide. In some embodiments, at least 95 wt.% of the coke may be reacted in the strip zone 224.
  • from about 75 wt.% to about 99 wt.% of the coke may be reacted in the strip zone 224, such as from about 75 wt.% to about 95 wt.%, from about 75 wt.% to about 90 wt.%, from about 75 wt.% to about 85 wt.%, from about 75 wt.% to about 80 wt.%, from about 80 wt.% to about 99 wt.%, from about 80 wt.% to about 95 wt.%, from about 80 wt.% to about 85 wt.%, from about 85 wt.% to about 99 wt.%, from about 85 wt.% to about 95 wt.%, from about 85 wt.% to about 90 wt.%, from about 90 wt.% to about 99 wt.%, from about 90 wt.% to about 95 wt.%, or from about 95 wt.% to about 99
  • the particulate solid may comprise less than 1.0 wt.% of coke when passed to the regeneration unit 300.
  • the majority of the carbon dioxide that is produced in the methods described herein may be produced in the strip zone and subsequently passed out of the strip zone and combined with the one or more olefinic compounds.
  • at least 80 wt.% of the total coke that is reacted in the strip zone and the regeneration unit may be reacted in the strip zone.
  • At least 85 wt.%, at least 90 wt.%, at least 95 wt.%, or even at least 99 wt.% of the total coke that is reacted in the strip zone and the regeneration unit may be reacted in the strip zone.
  • the majority (greater than 50 mol.%) of the carbon dioxide that is produced in the strip zone may be passed out of the strip zone and combined with the one or more olefinic compounds, such as at least 60 mol.%, at least 70 mol.%, 80 mol.%, 90 mol.%, 95 mol.%, or even 99 mol.%.
  • the combination of these two schemes may allow for the vast majority of carbon dioxide produced to be passed out of the reactor system 102 in a stream containing the reaction products, rather than the flue gas stream exiting the regeneration unit 300.
  • the coke that may form on the particulate solid may be primarily combusted within the strip zone 224 with sometimes lesser (such as little to no coke combustion) within the regeneration unit 300.
  • the combustion of coke may produce CO2 which may require relatively difficult downstream separation and processing steps when mixed with other gases such as hydrocarbons.
  • the product stream may already require downstream processing and separation steps, as such, it may be advantageous to pass much of the CO2 that is produced through the same stream as the products to utilize the already required downstream processing and separation operations, according to one or more embodiments. Therefore, less CO2 is passed to the atmosphere via the flue gas.
  • the addition of an oxygen-containing gas to the strip zone 224 combined with flowing a particulate solid and the oxygen-containing gas in a countercurrent flow pattern through the strip zone 224 may combust a majority of or essentially all of the coke that forms on the particulate solid within the strip zone 224.
  • Such a strip zone 224 configuration may allow the particulate solid to enter the regeneration unit 300 with little or no coke formed on the particulate solid which may reduce or eliminate the production of CO2 within the regeneration unit 300.
  • the primary component of the exhaust from the regeneration unit 300 may be water which can be safely emitted into the atmosphere limiting the amount of necessary processing of the regeneration unit exhaust and reducing the cost of running the reactor system.
  • the strip zone 224 may comprise a third gas inlet 530 where a fuel may be injected. In one or more embodiments a fuel may enter the strip zone 224 through the third gas inlet 530.
  • the third gas inlet 530 may be above the first gas inlet 520 and the second gas inlet 510. In some embodiments, the third gas inlet 530 may be between the first gas inlet 520 and the second gas inlet 510. In some embodiments, the third gas inlet 530 may be beneath the first gas inlet 520 and the second gas inlet 510. In some embodiments, the third gas inlet 530 may be at the same height as the first gas inlet 520 and the second gas inlet 510.
  • the fuel may comprise hydrogen, methane, ethane, propane, natural gas, or combinations thereof.
  • the concentration of fuel in the strip zone 224 may be greater than 20 mol.%. In some embodiments, the concentration of fuel in the strip zone 224 may be from about 5 mol.% to about 20 mol.%, from about 5 mol.% to about 15 mol.%, from about 5 mol.% to about 10 mol.%, from about 10 mol.% to about 20 mol.%, from about 10 mol.% to about 15 mol.%, or from about 15 mol.% to about 20 mol.%. In some embodiments, the strip zone 224 may not comprise a third gas inlet 530 (not pictured in FIG. 1).
  • the reactor system 104 is identical to the reactor system 102 of FIG. 1 except the strip zone comprises a single gas inlet 540.
  • oxygen in an oxygen-containing gas and a strip gas may enter the strip zone 224 through gas inlet 540.
  • these streams may be combined upstream of entrance to the strip zone 224.
  • a mixture of steam and air may enter the strip zone 224 through the gas inlet 540.
  • air may enter the strip zone 224 through gas inlet 540.
  • the particulate solid and gases within the strip zone 224 may move in a countercurrent flow pattern as the particulate solid moves in a generally downwards direction and the gases move in a generally upwards direction through the strip zone 224.
  • the oxygen and the nitrogen may be passed into the strip zone 224 through a single gas inlet (such as inlet 540) as an air stream.
  • the air stream encompasses at least nitrogen as the strip gas as well as oxygen, since air includes both nitrogen and oxygen.
  • Such an embodiment may eliminate the need for separate oxygen-containing gas stream and stripping gas streams.
  • the separation device 220 may be a cyclonic separation system, which may include two or more stages of cyclonic separation.
  • the first separation device into which the fluidized stream enters is referred to a primary cyclonic separation device.
  • the fluidized effluent from the primary cyclonic separation device may enter into a secondary cyclonic separation device for further separation.
  • Primary cyclonic separation devices may include, for example, primary cyclones, and systems commercially available under the names VSS (commercially available from UOP), LD2 (commercially available from Stone and Webster), and RS2 (commercially available from Stone and Webster).
  • Primary cyclones are described, for example, in U.S. Patent Nos. 4,579,716; 5,190,650; and 5,275,641, which are each incorporated by reference in their entirety herein.
  • one or more set of additional cyclones e.g. secondary cyclones and tertiary cyclones, are employed for further separation of the particulate solid from the product gas. It should be understood that any primary cyclonic separation device may be used in embodiments of the invention.
  • the separated particulate solid is passed from the particulate solid separation section 210 to the combustor 350.
  • the particulate solid may be processed by, for example, combustion with oxygen.
  • the particulate solid may be de-coked and/or fuel may be combusted to heat the particulate solid.
  • the particulate solid is then passed out of the combustor 350 and through the riser 330 to a riser termination separator 378, where the gas and solid components from the riser 330 are at least partially separated.
  • the vapor and remaining solids are transported to a secondary separation device 320 in the particulate solid separation section 310 where the remaining particulate solid is separated from the gases from the particulate solid processing (e.g., gases emitted by combustion of spent particulate solid or fuel, referred to herein as flue gas).
  • the flue gas may pass out of the regeneration unit 300 via outlet pipe 432.
  • the flue gas that passes out of the regeneration unit 300 via outlet pipe 432 may comprise less than 5 mol.% carbon dioxide (for example, in additional embodiments, less than or equal to 4 mol.%, 3 mol.%, 2 mol.%, 1 mol.%, or even 0.5 mol.% or 0.25 mol.%).
  • the flue gas that passes out of the regeneration unit 300 via outlet pipe 432 may not comprise carbon dioxide.
  • the separated particulate solid is then passed through the oxygen treatment zone 370 within the particulate solid separation section 310 to the upstream reactor section 250 via standpipe 424 and transport riser 430, where it is further utilized in a catalytic reaction.
  • the particulate solid in operation, may cycle between the reactor portion 200 and the regeneration unit 300.
  • the processed chemical streams, including the feed streams and product streams may be gaseous, and the particulate solid may be fluidized particulate solid.
  • the combustor 350 of the regeneration unit 300 may include one or more lower reactor portion inlet ports 352 and may be in fluid communication with the riser 330.
  • Oxy gen-containing gas such as air, may be passed through pipe 428 into the combustor 350.
  • the combustor 350 may be in fluid communication with the particulate solid separation section 210 via standpipe 426, which may supply spent particulate solid from the reactor portion 200 to the regeneration unit 300 for regeneration.
  • the combustor 350 and riser 330 may operate with similar or identical fluidization regimes as to what was disclosed with respect to the upstream reactor section 250 and downstream reactor section 230 of the reactor portion 200. That is, the combustor 350 may operate as a fluidized bed, such as in a fast fluidized, turbulent, or bubbling bed upflow reactor, while the riser 330 may operate in more of a plug flow manner, such as in a riser reactor. Geometries as described with respect to the upstream reactor section 250 and downstream reactor section 230 may equally apply to the combustor 350 and riser 330. Additionally, the combustor 350 may also include a fuel inlet 354, which may supply a fuel, such as a hydrocarbon stream or hydrogen, to the combustor 350.
  • the oxygen treatment zone 370 includes a fluid solids contacting device.
  • the fluid solids contacting device may include baffles or grid structures to facilitate contact of the processed particulate solid with the oxygen-containing gas. Examples of fluid solid contacting devices are described in further detail in U.S. Patent Nos. 9,827,543 and 9,815,040.
  • the fluidization regime within the oxygen treatment zone 370 may be bubbling bed type fluidization.
  • the oxygen treatment zone 370 may include an oxygen-containing gas inlet 372, which may supply an oxy gen-containing gas to the oxygen treatment zone 370 for oxygen treatment of the particulate solid.
  • the reactor system 102 described herein may be utilized to produce olefinic compounds from hydrocarbon feed streams.
  • olefinic compounds refers to hydrocarbons having one or more carbon-carbon double bonds apart from the formal double bonds in aromatic compounds.
  • ethylene and styrene are olefinic compounds, but ethylbenzene would not be an olefinic compound as the only double bonds present in ethylbenzene are formal double bonds present as part of the aromatic structure.
  • Olefinic compounds may be produced from a variety of hydrocarbon feed streams by utilizing different reaction mechanisms.
  • olefinic compounds may be produced by at least dehydrogenation reactions, cracking reactions, dehydration reactions, and methanol-to-olefin reactions. These reaction types may utilize different feed streams and different particulate solids to produce olefinic compounds. It should be understood that when “catalysts” are referred to herein, they may equally refer to the particulate solid referenced with respect to the system of FIG. 1 and FIG. 2.
  • the reaction may be a dehydrogenation reaction.
  • the one or more hydrocarbons may be a hydrocarbon feed stream the hydrocarbon feed stream may comprise one or more of ethylbenzene, ethane, propane, n- butane, and i-butane.
  • the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of ethylbenzene.
  • the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of ethane.
  • the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of propane.
  • the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of n- butane. In additional embodiments, the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of i-butane.
  • the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of the sum of ethylbenzene, ethane, propane, n-butane, and i-butane.
  • the dehydrogenation reaction may utilize gallium and/or platinum particulate solids as a catalyst.
  • the particulate solids may comprise a gallium and/or platinum catalyst.
  • a gallium and/or platinum catalyst comprises gallium, platinum, or both.
  • the gallium and/or platinum catalyst may be carried by an alumina or alumina silica support, and may optionally comprise potassium.
  • Such gallium and/or platinum catalysts are disclosed in U.S. Pat. No. 8,669,406, which is incorporated herein by reference in its entirety. However, it should be understood that other suitable catalysts may be utilized to perform the dehydrogenation reaction.
  • the reaction mechanism may be dehydrogenation followed by combustion (in the same chamber).
  • a dehydrogenation reaction may produce hydrogen as a byproduct, and an oxygen carrier material may contact the hydrogen and promote combustion of the hydrogen, forming water.
  • Examples of such reaction mechanisms which are contemplated as possible reactions mechanisms for the systems and methods described herein, are disclosed in WO 2020/046978 and U.S. Pat. Pub. No. 2021/0292259 the teachings of which are incorporated by reference in their entireties herein.
  • the particulate solid may comprise an oxygen-carrier material and a dehydrogenation catalyst material.
  • the particulate solid may consist essentially of the oxygen-carrier material.
  • “consists essentially of’ refers to materials with less than 1 wt. % of the non-recited materials (i.e., consisting essentially of A means A is at least 99 wt.% of the composition).
  • the particulate solid may not comprise a dehydrogenation catalyst material.
  • the oxygen-carrier material and the dehydrogenation catalyst material may be separate particles of the particulate solid.
  • the oxygen-carrier material and the dehydrogenation catalyst may be contained in the same particles of the particulate solid.
  • the dehydrogenation of the one or more hydrocarbons may be at least partially by catalytic dehydrogenation.
  • Catalytic dehydrogenation is the dehydrogenation of a hydrocarbon that is promoted by the use of a dehydrogenation catalyst.
  • the dehydrogenation reaction may be a non-catalytic thermal dehydrogenation reaction.
  • Non-catalytic thermal dehydrogenation refers to the dehydrogenation of a hydrocarbon that occurs without the use of a dehydrogenation catalyst and instead may occur because of high temperature, pressure or combinations thereof.
  • the particulate solid may comprise a “dual-purpose material” that may act as both a dehydrogenation catalyst as well as an oxygen-carrier material. It should be understood that, in at least the embodiments described herein where an oxygen-carrier material and a dehydrogenation catalyst are utilized in the same reaction vessel (such as those of FIG. 1 ), such a dual-purpose material may be utilized either in replacement or in combination with the oxygen-carrier material of the particulate solid or the dehydrogenation catalyst of the particulate solid.
  • the reaction may be a cracking reaction.
  • the hydrocarbon feed stream may comprise one or more of naphtha, n-butane, or i-butane.
  • the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of naphtha.
  • the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of n-butane. In additional embodiments, the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of i- butane.
  • the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of the sum of naphtha, n-butane, and i-butane.
  • the cracking reaction may utilize one or more zeolites as a catalyst.
  • the particulate solids may comprise one or more zeolites.
  • the one or more zeolites utilized in the cracking reaction may comprise a ZSM-5 zeolite.
  • suitable catalysts may be utilized to perform the cracking reaction.
  • suitable catalysts that are commercially available may include Intercat Super Z Excel or Intercat Super Z Exceed.
  • the cracking catalyst may comprise, in addition to a catalytically active material, platinum.
  • the cracking catalyst may include from 0.001 wt.% to 0.05 wt.% of platinum. The platinum may be sprayed on as platinum nitrate and calcined at an elevated temperature, such as around 700°C. Without being bound by theory, it is believed that the addition of platinum to the catalyst may allow for easier combustion of fuels, such as methane.
  • the reaction may be a dehydration reaction.
  • the hydrocarbon feed stream may comprise one or more of ethanol, propanol, or butanol.
  • the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of ethanol.
  • the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of propanol. In additional embodiments, the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of butanol.
  • the hydrocarbon feed stream or may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of the sum of ethanol, propanol, and butanol.
  • the dehydration reaction may utilize one or more acid catalysts.
  • the particulate solids may comprise one or more acid catalysts.
  • the one or more acid catalysts utilized in the dehydration reaction may comprise a zeolite (such as ZSM-5 zeolite), alumina, amorphous aluminosilicate, acid clay, or combinations thereof.
  • a zeolite such as ZSM-5 zeolite
  • alumina such as ZSM-5 zeolite
  • alumina such as alumina
  • amorphous aluminosilicate acid clay, or combinations thereof.
  • commercially available alumina catalysts which may be suitable, according to one or more embodiments, include SynDol (available from Scientific Design Company), V200 (available from UOP), or P200 (available from Sasol).
  • zeolite catalysts which may be suitable include CBV 8014, CBV 28014 (each available from Zeolyst).
  • amorphous aluminosilicate catalysts which may be suitable include silica-alumina catalyst support, grade 135 (available from Sigma Aldrich). However, it should be understood that other suitable catalysts may be utilized to perform the dehydration reaction.
  • the reaction may be a methanol-to-olefin reaction.
  • the hydrocarbon feed stream may comprise methanol.
  • the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.% or even at least 99 wt.% of methanol.
  • the methanol-to-olefin reaction may utilize one or more zeolites as a catalyst.
  • the particulate solids may comprise one or more zeolites.
  • the one or more zeolites utilized in the methanol-to-olefin reaction may comprise a one or more of a ZSM-5 zeolite or a SAPO-34 zeolite.
  • other suitable catalysts may be utilized to perform the methanol-to-olefin reaction.
  • the particulate solid may be capable of fluidization.
  • the particulate solid may exhibit properties known in the industry as “Geldart A” or “Geldart B” properties. Particles may be classified as “Group A” or “Group B” according to D. Geldart, Gas Fluidization Technology, John Wiley & Sons (New York, 1986), 34-37; and D. Geldart, “Types of Gas Fluidization,” Powder Technol. 7 (1973) 285-292, which are incorporated herein by reference in their entireties.
  • Group A is understood by those skilled in the art as representing an aeratable powder, having a bubble-free range of fluidization; a high bed expansion; a slow and linear deaeration rate; bubble properties that may include a predominance of splitting/recoalescing bubbles, with a maximum bubble size and large wake; high levels of solids mixing and gas backmixing, assuming equal U-Umf (U is the velocity of the carrier gas, and Umf is the minimum fluidization velocity, typically though not necessarily measured in meters per second, m/s, i.e., there is excess gas velocity); axisymmetric slug properties; and no spouting, except in very shallow beds.
  • the properties listed tend to improve as the mean particle size decreases, assuming equal cfp; or as the ⁇ 45 micrometers (pm) proportion is increased; or as pressure, temperature, viscosity, and density of the gas increase.
  • the particles may exhibit a small mean particle size and/or low particle density ( ⁇ 1.4 grams per cubic centimeter, g/cm 3 ), fluidize easily, with smooth fluidization at low gas velocities, and may exhibit controlled bubbling with small bubbles at higher gas velocities.+
  • Group B is understood by those skilled in the art as representing a “sand-like” powder that starts bubbling at Umf; that exhibits moderate bed expansion; a fast deaeration; no limits on bubble size; moderate levels of solids mixing and gas backmixing, assuming equal U-Umf; both axisymmetric and asymmetric slugs; and spouting in only shallow beds. These properties tend to improve as mean particle size decreases, but particle size distribution and, with some uncertainty, pressure, temperature, viscosity, or density of gas seem to do little to improve them.
  • the olefinic compounds may be present in a “product stream” sometimes called an “olefin-containing effluent”. Such a stream exits the reactor system of FIG. 1 and may be subsequently processed.
  • the olefinic compounds may comprise one or more of ethylene, propylene, butylene, or styrene.
  • the term butylene includes any isomers of butylene, such as a-butylene, cis-p-butylene, trans-p-butylene, and isobutylene.
  • the olefin-containing effluent may comprise at least 50 wt. %, at least 60 wt.
  • the olefin-containing effluent may comprise at least 50 wt. %, at least 60 wt. %, at least 70 wt. %, at least 80 wt. %, at least 90 wt. %, at least 95 wt. % or even at least 99 wt. % of ethylene.
  • the olefin-containing effluent may comprise at least 50 wt. %, at least 60 wt. %, at least 70 wt. %, at least 80 wt. %, at least 90 wt. %, at least 95 wt. % or even at least 99 wt. % of propylene.
  • the olefin- containing effluent may comprise at least 50 wt. %, at least 60 wt.
  • the olefin-containing effluent may comprise at least 50 wt. %, at least 60 wt. %, at least 70 wt. %, at least 80 wt. %, at least 90 wt. %, at least 95 wt. % or even at least 99 wt. % of butylene.
  • the olefin-containing effluent may comprise at least 50 wt. %, at least 60 wt. %, at least 70 wt. %, at least 80 wt. %, at least 90 wt. %, at least 95 wt. % or even at least 99 wt. % of styrene.
  • the olefin-containing effluent may comprise at least 50 wt. %, at least 60 wt.
  • the olefin-containing effluent may further comprise unreacted components of the feed stream, as well as other reaction products that are not considered light olefins.
  • the olefinic compounds may be separated from unreacted components in subsequent separation steps.
  • a first aspect is a method for forming olefinic compounds, the method comprising: contacting a feed stream comprising one or more hydrocarbons with a particulate solid in a reactor, wherein in the reactor: the one or more hydrocarbons are reacted to form one or more olefinic compounds; and coke is formed on the particulate solid; passing the particulate solid from the reactor to a strip zone, wherein: the particulate solid is contacted with a strip gas and oxygen in the strip zone; the strip gas comprises nitrogen, steam, or combinations thereof; in the strip zone, a majority of the coke is reacted with oxygen to form carbon dioxide; the majority of the carbon dioxide produced in the strip zone is passed out of the strip zone and combined with the one or more olefinic compounds; passing the particulate solid from the strip zone to a regeneration unit, wherein the particulate solid is heated by combustion of a fuel in the regeneration unit; and passing at least a portion of the particulate
  • Another aspect includes any previous aspect or combination of aspects, wherein at least 80 wt.% of the total coke that is reacted in the strip zone and the regeneration unit is reacted in the strip zone.
  • Another aspect includes any previous aspect or combination of aspects, wherein the particulate solid comprises less than 1.0 wt.% of coke when passed to the regeneration unit.
  • Another aspect includes any previous aspect or combination of aspects, wherein the particulate solid moves in a generally downward direction through the strip zone and gases move in a generally upwards direction through the strip zone, such that the particulate solid and gases move in a countercurrent flow pattern through the strip zone.
  • Another aspect includes any previous aspect or combination of aspects, wherein the oxygen is passed into the strip zone in an oxygen-containing gas, and the oxygen-containing gas and the strip gas enter into the strip zone through separate gas inlets.
  • Another aspect includes any previous aspect or combination of aspects, wherein the strip zone comprises a first gas inlet, a second gas inlet, and a third gas inlet, and wherein: the oxygencontaining gas enters into the strip zone through the first gas inlet; the strip gas enters into the strip zone through the second gas inlet; a fuel enters into the strip zone through the third gas inlet; the first gas inlet is above the second gas inlet; and the third gas inlet is above the first gas inlet.
  • strip gas comprises nitrogen
  • oxygen and the nitrogen are passed into the strip zone through a single gas inlet as an air stream.
  • fuel comprises hydrogen.
  • Another aspect includes any previous aspect or combination of aspects, wherein the amount of carbon dioxide in the flue gas from the regeneration unit is less than or equal to 0.5 mol.% of the flue gas.
  • Another aspect includes any previous aspect or combination of aspects, wherein a portion of the particulate solid is withdrawn from the strip zone and passed to the reactor without first passing through the regeneration unit.
  • Another aspect includes any previous aspect or combination of aspects, wherein the reaction in the reactor is a dehydrogenation reaction; the one or more hydrocarbons comprise ethylbenzene, ethane, propane, n-butane, i-butane, or combinations thereof; and the particulate solid comprises a dehydrogenation catalyst, an oxygen-carrier material, or both.
  • the reaction in the reactor is a dehydrogenation reaction
  • the one or more hydrocarbons comprise ethylbenzene, ethane, propane, n-butane, i-butane, or combinations thereof
  • the particulate solid comprises a dehydrogenation catalyst, an oxygen-carrier material, or both.
  • Another aspect includes any previous aspect or combination of aspects, wherein the reaction in the reactor is a non-catalytic thermal dehydrogenation reaction; the one or more hydrocarbons comprise ethylbenzene, ethane, propane, n-butane, i-butane, or combinations thereof; and the particulate solid consists essentially of an oxygen-carrier material.
  • Another aspect includes any previous aspect or combination of aspects, wherein the reaction in the reactor is a cracking reaction; the one or more hydrocarbons comprise naphtha, n- butane, i-butane, or combinations thereof; and the particulate solid comprises one or more zeolites.
  • Another aspect includes any previous aspect or combination of aspects, wherein: the reaction in the reactor is a dehydration reaction; the one or more hydrocarbons comprise ethanol, propanol, butanol, or combinations thereof; and the particulate solid comprises one or more acid catalysts.
  • Another aspect includes any previous aspect or combination of aspects, wherein: the reaction in the reactor is a methanol-to-olefin reaction; the one or more hydrocarbons may comprise methanol; and the particulate solid comprises one or more zeolites.
  • the reaction in the reactor is a methanol-to-olefin reaction; the one or more hydrocarbons may comprise methanol; and the particulate solid comprises one or more zeolites.
  • compositions are described as “comprising” one or more elements, embodiments of that composition “consisting of’ or “consisting essentially of’ those one or more elements is contemplated herein.
  • chemicals or chemical streams are described as “passing” from one system unit or portion of a system unit to another.
  • passing may include direct passing or indirect passing.
  • direct passing has no intermediate destination between unit A and unit B (i.e., directly through a pipe or other transport passage)
  • indirect passing may include one or more intermediate destinations between unit A and unit B.
  • a stream passing from unit A to unit B may passed through, without limitation, a heat exchanger, treatment device, etc.
  • compositional ranges of a chemical constituent in a stream or in a reactor should be appreciated as containing, in some embodiments, a mixture of isomers of that constituent.
  • a compositional range specifying butene may include a mixture of various isomers of butene.
  • the examples supply compositional ranges for various streams, and that the total amount of isomers of a particular chemical composition can constitute a range.
  • any two quantitative values assigned to a property may constitute a range of that property, and all combinations of ranges formed from all stated quantitative values of a given property are contemplated in this disclosure. Where multiple ranges for a quantitative value are provided, these ranges may be combined to form a broader range, which is contemplated in the embodiments described herein.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Crystallography & Structural Chemistry (AREA)
  • Devices And Processes Conducted In The Presence Of Fluids And Solid Particles (AREA)

Abstract

Selon un ou plusieurs modes de réalisation de la présente invention, des composés oléfiniques peuvent être formés par un procédé comprenant la mise en contact d'un flux d'alimentation comprenant un ou plusieurs hydrocarbures avec un solide particulaire dans un réacteur. Dans le réacteur, l'hydrocarbure ou les hydrocarbures peuvent être mis à réagir pour former un ou plusieurs composés oléfiniques et du coke peut se former sur la matière solide particulaire. La matière solide particulaire peut passer du réacteur à une zone d'extraction. Dans la zone d'extraction, la matière solide particulaire peut être mise en contact avec un gaz d'extraction et de l'oxygène. Le gaz d'extraction peut comprendre de l'azote, de la vapeur ou des combinaisons de ceux-ci. Dans la zone d'extraction, une majorité du coke peut être mis à réagir avec de l'oxygène pour former du dioxyde de carbone. La majorité du dioxyde de carbone produit dans la zone d'extraction peut être sortie de la zone d'extraction et combinée avec le ou les composés oléfiniques.
PCT/US2023/074024 2022-09-14 2023-09-13 Procédés de réaction d'hydrocarbures à l'aide de dispositifs d'extraction WO2024059602A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US202263406445P 2022-09-14 2022-09-14
US63/406,445 2022-09-14

Publications (1)

Publication Number Publication Date
WO2024059602A1 true WO2024059602A1 (fr) 2024-03-21

Family

ID=88373897

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2023/074024 WO2024059602A1 (fr) 2022-09-14 2023-09-13 Procédés de réaction d'hydrocarbures à l'aide de dispositifs d'extraction

Country Status (1)

Country Link
WO (1) WO2024059602A1 (fr)

Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4579716A (en) 1983-09-06 1986-04-01 Mobil Oil Corporation Closed reactor FCC system with provisions for surge capacity
US5190650A (en) 1991-06-24 1993-03-02 Exxon Research And Engineering Company Tangential solids separation transfer tunnel
WO2005077867A2 (fr) * 2004-02-09 2005-08-25 The Dow Chemical Company Procede d'elaboration de composes d'hydrocarbure deshydrogenes
WO2016160273A1 (fr) * 2015-03-30 2016-10-06 Dow Global Technologies Llc Procédé intégré de déshydrogénation d'hydrocarbures c3-c4
US9815040B2 (en) 2015-06-26 2017-11-14 Dow Global Technologies Llc Fluid solids contacting device
US9827543B2 (en) 2015-06-30 2017-11-28 Dow Global Technologies Llc Fluid solids contacting device
WO2020009863A1 (fr) * 2018-07-05 2020-01-09 Dow Global Technologies Llc Procédés et systèmes chimiques comprenant la combustion de combustibles supplémentaires
WO2020046978A1 (fr) 2018-08-31 2020-03-05 Dow Global Technologies Llc Procédés de déshydrogénation d'hydrocarbures

Patent Citations (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4579716A (en) 1983-09-06 1986-04-01 Mobil Oil Corporation Closed reactor FCC system with provisions for surge capacity
US5190650A (en) 1991-06-24 1993-03-02 Exxon Research And Engineering Company Tangential solids separation transfer tunnel
US5275641A (en) 1991-06-24 1994-01-04 Exxon Research & Engineering Co. Improved method for transferring entrained solids to a cyclone
WO2005077867A2 (fr) * 2004-02-09 2005-08-25 The Dow Chemical Company Procede d'elaboration de composes d'hydrocarbure deshydrogenes
US8669406B2 (en) 2004-02-09 2014-03-11 Dow Global Technologies Llc Process for the preparation of hydrogenated hydrocarbon compounds
WO2016160273A1 (fr) * 2015-03-30 2016-10-06 Dow Global Technologies Llc Procédé intégré de déshydrogénation d'hydrocarbures c3-c4
US9815040B2 (en) 2015-06-26 2017-11-14 Dow Global Technologies Llc Fluid solids contacting device
US9827543B2 (en) 2015-06-30 2017-11-28 Dow Global Technologies Llc Fluid solids contacting device
WO2020009863A1 (fr) * 2018-07-05 2020-01-09 Dow Global Technologies Llc Procédés et systèmes chimiques comprenant la combustion de combustibles supplémentaires
WO2020046978A1 (fr) 2018-08-31 2020-03-05 Dow Global Technologies Llc Procédés de déshydrogénation d'hydrocarbures
US20210292259A1 (en) 2018-08-31 2021-09-23 Dow Global Technologies Llc Methods for dehydrogenating hydrocarbons

Non-Patent Citations (2)

* Cited by examiner, † Cited by third party
Title
D. GELDART: "Gas Fluidization Technology", 1986, JOHN WILEY & SONS, pages: 34 - 37
D. GELDART: "Types of Gas Fluidization", POWDER TECHNOL., vol. 7, 1973, pages 285 - 292, XP002669531, DOI: 10.1016/0032-5910(73)80037-3

Similar Documents

Publication Publication Date Title
US11459282B2 (en) Methods for forming light olefins by cracking
US11059763B2 (en) Methods and apparatuses for processing gas streams
US20240033723A1 (en) Systems and methods for regenerating particulate solids
US11479521B2 (en) Methods for making light olefins from different feed streams
US20240034700A1 (en) Systems and methods for producing olefins
WO2024059602A1 (fr) Procédés de réaction d'hydrocarbures à l'aide de dispositifs d'extraction
US11987547B2 (en) Methods for forming light olefins that include use of cooled product as a recycled quench stream
WO2024118459A1 (fr) Procédés de déshydrogénation d'hydrocarbures utilisant de multiples entrées de catalyseur
WO2024118461A1 (fr) Distributeurs solides particulaires appropriés pour distribuer de multiples flux solides particulaires
WO2024118463A1 (fr) Procédés de production de composés oléfiniques utilisant des régénérateurs
WO2024118462A1 (fr) Procédés de production de composés oléfiniques à l'aide de chambres de combustion
WO2023192906A1 (fr) Procédés de formation d'oléfines légères au moyen de systèmes d'échangeur de chaleur
WO2024118432A1 (fr) Procédés pour constituer des oléfines légères avec recyclage du catalyseur
WO2024118433A1 (fr) Procédés de formation d'oléfines légères utilisant des cuves d'oxydation
WO2023244971A1 (fr) Procédés de fabrication d'oléfines légères par déshydrogénation à l'aide de catalyseurs comprenant du chrome
WO2024092196A1 (fr) Procédés de fonctionnement de récipients de traitement chimique qui comprennent des épaulements
WO2023244958A1 (fr) Catalyseurs appropriés pour la fabrication d'oléfines légères par déshydrogénation qui comprennent du chrome
WO2023244965A1 (fr) Procédés de fabrication d'oléfines légères par déshydrogénation à l'aide de catalyseurs comprenant du fer
WO2024118436A1 (fr) Procédés de formation de produits déshydrogénés utilisant une dérivation de combustion d'un certain catalyseur
WO2023244943A1 (fr) Procédés de fabrication d'oléfines légères par déshydrogénation à l'aide de catalyseurs comprenant du manganèse
WO2023244969A1 (fr) Catalyseurs appropriés pour la fabrication d'oléfines légères par déshydrogénation, lesquels comprennent du fer
WO2023244941A1 (fr) Procédés de fabrication d'oléfines légères comprenant la modification de catalyseurs
WO2023244939A1 (fr) Procédés de fabrication d'oléfines légères par déshydrogénation qui utilisent des additifs de combustion
WO2023244938A1 (fr) Procédés de fabrication d'oléfines légères par déshydrogénation utilisant des additifs de combustion comprenant des métaux de transition
WO2024059600A1 (fr) Procédés de déshydrogénation d'hydrocarbures utilisant des régénérateurs

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 23789437

Country of ref document: EP

Kind code of ref document: A1